Fluid injection system

ABSTRACT

A system including a fluid injection system configured to removably couple to a mineral extraction system, wherein the fluid injection system includes a fluid injection system controller, a flow meter system coupled to the fluid injection system controller, wherein the flow meter system is configured to measure a fluid flow of a fluid through the fluid injection system, an adjustable valve configured to control the fluid flow through the fluid injection system, and a non-return valve configured to block reverse flow of the fluid through the fluid injection system, wherein the fluid injection system controller, the flow meter system, the adjustable valve, and the non-return valve are coupled to a common housing.

CROSS REFERENCE TO RELATED APPLICATION

This application is a continuation of U.S. patent application Ser. No.14/023,413, entitled “FLUID INJECTION SYSTEM”, filed Sep. 10, 2013,which is herein incorporated by reference in its entirety.

BACKGROUND

This section is intended to introduce the reader to various aspects ofart that may be related to various aspects of the present invention,which are described and/or claimed below. This discussion is believed tobe helpful in providing the reader with background information tofacilitate a better understanding of the various aspects of the presentinvention. Accordingly, it should be understood that these statementsare to be read in this light, and not as admissions of prior art.

Wells are often used to access resources below the surface of the earth.For instance, oil, natural gas, and water are often extracted via awell. Some wells are used to inject materials below the surface of theearth, e.g., to sequester carbon dioxide, to store natural gas for lateruse, or to inject steam or other substances near an oil well to enhancerecovery. Due to the value of these subsurface resources, wells areoften drilled at great expense, and great care is typically taken toextend their useful life.

Chemical-injection management systems are often used to maintain a welland/or enhance well output. For example, chemical-injection managementsystems may inject chemicals to extend the life of a well or increasethe rate at which resources are extracted from a well. Typically, thesematerials are injected into the well in a controlled manner over aperiod of time by the chemical-injection management system.

BRIEF DESCRIPTION OF THE DRAWINGS

Various features, aspects, and advantages of the present invention willbecome better understood when the following detailed description is readwith reference to the accompanying figures in which like charactersrepresent like parts throughout the figures, wherein:

FIG. 1 is a block diagram of an embodiment of an exemplary resourceextraction system;

FIG. 2 is a partial perspective view of an embodiment of a Christmastree with a fluid injection system;

FIG. 3 is an exploded perspective view of an embodiment of a receptacleand a fluid injection system;

FIG. 4 is a bottom view of an embodiment of a fluid injection system;and

FIG. 5 is a schematic of an embodiment of a fluid injection system.

DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS

One or more specific embodiments of the present invention will bedescribed below. These described embodiments are only exemplary of thepresent invention. Additionally, in an effort to provide a concisedescription of these exemplary embodiments, all features of an actualimplementation may not be described in the specification. It should beappreciated that in the development of any such actual implementation,as in any engineering or design project, numerousimplementation-specific decisions must be made to achieve thedevelopers' specific goals, such as compliance with system-related andbusiness-related constraints, which may vary from one implementation toanother. Moreover, it should be appreciated that such a developmenteffort might be complex and time consuming, but would nevertheless be aroutine undertaking of design, fabrication, and manufacture for those ofordinary skill having the benefit of this disclosure.

The present disclosure is generally directed toward a fluid injectionsystem, such as a chemical injection metering valve (CIMV) system, whichincludes a flow meter system, an adjustable valve, and a non-returnvalve in a single module. The module is capable of insertion and removalfrom a sub-sea mineral extraction system with a remotely operatedvehicle (ROV), which facilitates and reduces costs for repairing,inspecting, or replacing fluid injection systems. In operation, thefluid injection system enables measurement and control of fluids used inmineral extraction operations. For example, the fluid injection systemmay measure and control fluids used to increase resource extraction orto increase the operating life of a well.

Certain exemplary embodiments of the fluid injection system include aflow meter system that uses ultrasonic transducers to measure fluid flowrates. A controller uses the measurements from the flow meter system tocontrol the flow rates (i.e., reduce or increase the flow rates) throughthe fluid injection system with an adjustable valve. In otherembodiments, the fluid injection system may also include a pressuretransducer system capable of measuring fluid pressure. The combinationof the ultrasonic flow meter system and the pressure transducer systemenables redundant measurement or backup measurement of fluid flow ratesthrough the fluid injection system. In certain embodiments, thecontroller may use sensors that provide positional feedback to controlthe adjustable valve's position. For example, some embodiments mayinclude a position sensor and/or a shaft rotation sensor that providesthe controller positional information about the adjustable valve. Theinclusion of the shaft rotation sensor and the position sensor enablesredundant position information and/or backup position information to thecontroller for controlling the adjustable valve.

FIG. 1 depicts an exemplary sub-sea resource extraction system 10. Inparticular, the sub-sea resource extraction system 10 may be used toextract oil, natural gas, and other related resources from a well 12,located on a sub-sea floor 14, to an extraction point 16 at a surfacelocation 18. The extraction point 16 may be an on-shore processingfacility, an offshore rig, or any other extraction point. The sub-searesource extraction system 10 may also be used to inject fluids, such aswater, gas, chemicals, and so forth, into the well 12 through anunderwater fluid injection system 20 (e.g., a chemical-injection system,such as a (CIMV system) on a Christmas tree 22. For example, theremovable fluid injection system 20 may accurately injectcorrosion-inhibiting materials, foam-inhibiting materials,wax-inhibiting materials, and/or antifreeze to extend the life of a wellor increase the resource extraction rate from the well 12. Thesematerials may be injected into the well 12 in a controlled manner over aperiod of time by the fluid injection system 20. The working fluids maybe supplied to the sub-sea equipment using flexible jumper or umbilicallines 24. The flexible jumper or umbilical lines 24 may includereinforced polymer and small diameter steel supply lines, which areinterstitially spaced into a larger reinforced polymer liner.

FIG. 2 is a partial perspective view of an embodiment of the Christmastree 22 with the fluid injection system 20. The tree 22 couples to thewell 12 and may include a variety of valves, fittings, and controls forextracting resources out of the well 12. As illustrated, the Christmastree 22 includes the receptacle 40 that removably receives (e.g.,removably locks) the fluid injection system 20. The receptacle 40enables fluid and electrical communication between the Christmas tree 22and the fluid injection system 20. As will be discussed in detail below,when attached, the fluid injection system 20 measures and controls fluidflow into the well 12. For example, the fluid injection system 20 mayinject water, gas, corrosion-inhibiting materials, foam-inhibitingmaterials, wax-inhibiting materials, and/or antifreeze to extend thelife of a well or increase a mineral extraction rate out of the well.Again, these materials may be injected into the well in a controlledmanner over a period of time by the fluid injection system 20.

FIG. 3 is an exploded perspective view of an embodiment of thereceptacle 40 capable of receiving the fluid injection system 20. Thereceptacle 40 includes a guide funnel 50 with a sloped annular surface52 (e.g., a conical surface) that channels and aligns the fluidinjection system 20 during connection to the Christmas tree 22.Specifically, the guide funnel 50 gradually changes in diameter from afirst annular end 54 with a diameter 56 to a second annular end 58 witha diameter 60. The differences in diameters 56 and 60 define the angleor slope of the sloped surface 52. As illustrated, the guide funnel 50couples to a receptacle housing 62 (e.g., an annular receptacle housing)with bolts 64. When coupled, the sloped surface 52, of the guide funnel50, aligns and channels the fluid injection system 20 axially into thereceptacle housing 62. In some embodiments, the guide funnel 50 maycouple to the Christmas tree 22. For example, the second end 58 of theguide funnel 50 may include an annular flange 66 with apertures 68. Theflange 66 may receive bolts through the apertures 68 that couple theguide funnel 50 to the Christmas tree 22.

Coupled to the guide funnel 50 is the receptacle housing 62. Thereceptacle housing 62 receives and secures the fluid injection system 20between a first axial end 70 and a second axial end 72. As illustrated,the first end 70 couples to the guide funnel 50, while the second end 72couples to a receptacle body 74. In order to couple to the receptaclebody 74, the second end 72 of the receptacle housing 62 couples to anannular connection flange 76 on the receptacle body 74. Morespecifically, the second end 72 of the receptacle housing 62 includes anannular arrangement of apertures 78 that corresponds to an annulararrangement of apertures 80 on the connection flange 76. The apertures78 and 80 enable bolts 82 to couple the receptacle housing 62 to theconnection flange 76. When coupled, a first end 84 of the receptaclebody 74 projects into cavity 85 of the receptacle housing 62 forconnection to the fluid injection system 20. As illustrated, the firstend 84 of the receptacle body 74 includes a fluid inlet 86 (e.g.,chemical inlet), a fluid exit 88 (e.g., chemical outlet), and a guidepin receptacle 89. The fluid inlet 86 and the fluid exit 88 fluidlycouple to corresponding flanged connections 90 and 92 on a second end 94of the receptacle body 74. The flanged connections 90 and 92 fluidlycouple the receptacle 40 to the Christmas tree 22, enabling the fluidinjection system 20 to control fluid injection (e.g., chemicalinjection) from the extraction point 16 into the well 12. Furthermore,receptacle 40 may provide power and control signals to the fluidinjection system 20 through the electrical connector 96. The electricalconnector 96 in-turn receives power and control signals by coupling tothe Christmas tree 22 with one or more cables through the aperture 98 inthe receptacle housing 62.

In the illustrated embodiment, the fluid injection system 20 is a module99 capable of insertion into and removal from the receptacle 40 with aremotely operated vehicle (ROV). The ability to remove and insert thefluid injection system 20 with an ROV facilitates replacement or repairwithout the use of a running tool and the associated costs. Asillustrated, the fluid injection system 20 includes an over-pull handle100 and a remotely operated vehicle (ROV) torque bucket 102 for couplingand removal of the fluid injection system 20. The ROV bucket 102 couplesto a lockdown mechanism 104 that secures the fluid injection system 20within the receptacle housing 62. More specifically, the lockdownmechanism 104 secures the fluid injection system 20 with radiallymovable dogs 106 that engage a groove 108 in the receptacle housing 62.The dogs 106 are capable of extending radially into and retractingradially away from the groove 108 enabling the fluid injection system 20to be removed/coupled to the receptacle 40. In operation, an ROVactivates or deactivates the lockdown mechanism 104 by engaging a nutwithin the ROV bucket 102.

Coupled to the lockdown mechanism 104 is a housing 109, such as acylindrical or annular housing. As illustrated, the lockdown mechanism104 couples to the housing 109 with bolts 110. The housing 109 maycontain multiple components that measure and control fluid flow throughthe fluid injection system 20, and fluidly couple the fluid injectionsystem 20 to the receptacle 40. To facilitate alignment and coupling,the fluid injection system 20 includes a guide skirt 112 (e.g., anannular guide skirt). The guide skirt 112 couples to the housing 109with bolts 114. In the illustrated embodiment, the guide skirt 112includes an axial slot 116 that aligns with and engages a guide key 118on the receptacle body 74. More specifically, as the fluid injectionsystem 20 moves in axial direction 120, the guide skirt 112 enables thefluid injection system 20 to rotate and align as the slot 116 engagesthe guide key 118, thereby circumferentially aligning the fluid andelectrical connections (e.g., 86, 88, and 96). In some embodiments, theslot 116 may include an axial slot portion 122 and a converging slotportion 124. In operation, the converging slot portion 124 assists incircumferentially aligning the guide key 118 with the axial slot portion122. Accordingly, as the housing 109 moves axially in direction 120 theslot 116 enables circumferential alignment of the housing 109 with thereceptacle body 74. The circumferential alignment of the fluid injectionsystem 20 with the receptacle 40 enables fluid and electrical couplingbetween the receptacle body 74 and the fluid injection system 20.

FIG. 4 is a bottom view of the fluid injection system 20. Asillustrated, the fluid injection system 20 includes an electricalconnector 140, a fluid inlet coupler 142, a fluid outlet coupler 144,and an axial guide pin 146. As explained above, the engagement of theslot 116 with the guide key 118 circumferentially aligns (e.g.,rotationally about the axis of) the fluid injection system 20 with thereceptacle body 74. In some embodiments, the fluid injection system 20may also include the guide pin 146 that couples to the guide pinreceptacle 89 to facilitate radial or lateral alignment of electricalconnector 140, fluid coupler 142, and fluid coupler 144. The radialalignment enables the electrical connector 96 to electrically couple tothe electrical connector 140 removably in the axial direction, and thefluid couplers 142 and 144 to couple to the fluid inlet 86 and fluidoutlet 88 removably in the axial direction. The removable connectionbetween the electrical connector 96 and 140 enables the fluid injectionsystem 20 to receive power and electrical signals to control and powercomponents within the fluid injection system 20 to control and measurefluid flow. In some embodiments, the fluid injection system 20 maycommunicate with and receive instructions from an external mineralextraction system controller located on the Christmas tree 22 or at anextraction point 16. Moreover, the removable axial connection betweenfluid inlet coupler 142 and the fluid inlet 86 of the receptacle body74; and the fluid outlet coupler 144 and the fluid outlet 88 of thereceptacle body 74 enables fluid (e.g., one or more chemicals) to flowbetween the Christmas tree 22 and the fluid injection system 20.

FIG. 5 is a block diagram of the fluid injection system 20 that mayinclude a flow meter system 160, an adjustable valve 162, and anon-return valve 164 within a single removable module 166. As explainedabove, the fluid injection system 20 is capable of insertion and removalwith an ROV, thereby reducing costs and the difficulty associated withusing a running tool. In operation, the fluid injection system 20measures and controls the flow of a fluid 168 (e.g., water, gas,chemicals) into the sub-sea resource extraction system 10. These fluidsmay assist in the extraction of the mineral resource or increase theoperating life of the well 12. After fluidly coupling the module 166 toa Christmas tree 22 or other mineral extraction equipment, the fluid 168enters the fluid injection system 20 through the fluid inlet coupler142. As illustrated, the fluid inlet coupler 142 may include anon-return valve 164 (e.g., a one-way valve, a check valve, etc.) thatenables fluid flow into the fluid injection system 20, but blocks thereverse flow of fluid out of the fluid injection system 20.

After passing through the fluid inlet coupler 142 (e.g., a male plug,snap fit connector, etc.), the fluid 168 enters the flow meter system160. In the flow meter system 160 (e.g., a primary flow meter system),one or more ultrasonic transducers 170 measure the fluid flow into thefluid injection system 20. The ultrasonic transducers 170 measure flowspeeds by rapidly sending and receiving ultrasonic waves that travelthrough the fluid 168. A controller 172 (i.e., a fluid injection systemcontroller) couples to the flow meter system 160 and collects thetransmission and reception times by the ultrasonic transducers 170. Thecontroller 172 then calculates how the ultrasonic waves change throughthe fluid 168, enabling the controller 172 to calculate changes in thefluid flow. For example, the controller 172 may include a processor 174and memory 176, which the controller 172 uses to determine a volumetricflow rate, a mass flow rate, a volume, or a mass based on a signal fromthe flow meter system 160. The controller 172 may also regulate orcontrol one or more of these parameters based on the signal from theflow meter 160 by signaling the valve actuator 178 to adjust theadjustable valve 162. To this end, the controller 172 may includesoftware and/or circuitry configured to execute a control routine. Insome embodiments, the control routine and/or data based on a signal fromthe flow meter 160 may be stored in memory 176 or anothercomputer-readable medium. In some embodiments, the controller 172 (i.e.,a fluid injection system controller) may communicate with and receiveinstructions from a mineral extraction system controller located on theChristmas tree or at an extraction point 16.

In some embodiments, the fluid injection system 20 may also include apressure transducer system 180 (e.g., a secondary flow meter system)that enables redundant or backup flow rate measurements. The pressuretransducer system 180 includes a first pressure transducer 182 and asecondary pressure transducer 184 to measure fluid pressures atdifferent locations in the fluid injection system 20. As illustrated,the first pressure transducer 182 enables pressure measurements of thefluid 168 before the fluid passes through the adjustable valve 162,while the second pressure transducer 184 measures pressure after thefluid 168 passes through the adjustable valve 162. The controller 172compares the pressures sensed by the pressure transducers 182 and 184using known values about the fluid and valve position to calculate thefluid flow rate through the fluid injection system 20. Depending on theembodiment, the fluid injection system 20 may use the flow rate system160 and the pressure transducer system 180 simultaneously or separatelyto measure the flow rate of fluid 168.

As explained above, the controller 172 regulates or controls fluid flowbased signals from the flow meter system 160 and/or the pressuretransducer system 180. In operation, the controller 172 uses the signalsto exercise feedback control over fluid flow through the adjustablevalve 162 with the valve actuator 178. For example, the controller 172may transmit a control signal 142 to the valve actuator 178. The contentof the control signal 142 may be determined by, or based on, acomparison between a flow parameter (e.g., a volumetric flow rate, amass flow rate, a volume, or a mass) measured by the flow meter system160 or the pressure transducer system 180 and a desired flow parametervalue. For instance, if the controller 172 determines that the flow ratethrough the fluid injection system 20 is less than a desired flow rate,the controller 172 may signal the valve actuator 178 to open adjustablevalve 162 some distance. In response, a motor 186 may drive a gearbox188, and the gearbox 188 may transmit rotational movement from the motor186 into linear or rotational movement of the adjustable valve 162. As aresult, in some embodiments, the flow rate through the adjustable valve162 may increase as the adjustable valve 162 opens. Alternatively, ifthe controller 172 determines that the flow rate (or other flowparameter) through the fluid injection system 20 is greater than adesired flow rate (or other flow parameter), the controller 172 maysignal the valve actuator 178 to close the adjustable valve 162 somedistance, thereby decreasing the flow rate. In other words, thecontroller 172 may signal the valve actuator 178 to open or close theadjustable valve 162 some distance based on a flow parameter sensed bythe flow meter 160 or the pressure transducer system 180.

The controller 172 may monitor and control the position of theadjustable valve 162 with signals received from a position sensor 190and/or a shaft rotation sensor 192. As illustrated, the position sensor190 couples to the adjustable valve 162 and the shaft rotation sensor192 couples to the actuator 178. In this arrangement, the positionsensor 190 provides positional feedback to the controller 172 based onactual movement of the adjustable valve 162. In contrast, the shaftrotation sensor 192 provides indirect positional feedback of theadjustable valve 162 by sensing positional change of the actuator 178.In other words, the shaft rotation sensor 192 provides signals to thecontroller 172 indicating movement of the actuator 178, which thecontroller 172 then uses to determine movement of the adjustable valve162. The combination of the position sensor 190 and the shaft rotationsensor 192 provides the controller 172 redundant positional informationor backup positional information of the adjustable valve 162, enablingthe controller 172 to control fluid flow through fluid injection system20. After passing through the adjustable valve 162, the fluid 168 exitsthe fluid injection system 20 through a fluid outlet coupler 144 (e.g.,a male plug, snap fit connector, etc.) for use by the sub-sea resourceextraction system 10. In some embodiments, the fluid outlet coupler 144includes a non-return valve 164 (e.g., a one-way valve, a check valve,etc.) that blocks the reverse flow of the fluid 168 into the fluidinjection system 20.

While the invention may be susceptible to various modifications andalternative forms, specific embodiments have been shown by way ofexample in the drawings and have been described in detail herein.However, it should be understood that the invention is not intended tobe limited to the particular forms disclosed. Rather, the invention isto cover all modifications, equivalents, and alternatives falling withinthe spirit and scope of the invention as defined by the followingappended claims.

The invention claimed is:
 1. A system, comprising: a sub-sea retrievablemodule, comprising: a housing having a fluid inlet, a fluid outlet, anda flow path between the fluid inlet and the fluid outlet; a flow metersystem disposed in the housing along the flow path, wherein the flowmeter system is configured to measure a fluid flow of a fluid along theflow path; and a pressure measurement system disposed in the housingalong the flow path, wherein the pressure measurement system isconfigured to measure a fluid pressure along the flow path, and thesystem is configured to determine the fluid flow of the fluid along theflow path based on a measurement by the pressure measurement system. 2.The system of claim 1, wherein the fluid inlet and the fluid outlet aredisposed on a common side of the housing.
 3. The system of claim 2,wherein the fluid inlet and the fluid outlet are configured to removablycouple with first and second mating ports in an axial direction.
 4. Thesystem of claim 3, wherein the sub-sea retrievable module comprises anaxial guide disposed on the common side of the housing.
 5. The system ofclaim 3, wherein the sub-sea retrievable module comprises acircumferential alignment guide disposed on the common side of thehousing.
 6. The system of claim 2, wherein the sub-sea retrievablemodule comprises an electrical connector disposed on the common side ofthe housing.
 7. The system of claim 1, wherein the sub-sea retrievablemodule comprises a tool coupling configured to couple with a tool thatcan install or remove the sub-sea retrievable module.
 8. The system ofclaim 7, wherein the tool coupling comprises a remotely operated vehicle(ROV) coupling, and the tool comprises a ROV.
 9. The system of claim 1,wherein the flow meter system comprises a non-invasive flow metersystem.
 10. The system of claim 9, wherein the non-invasive flow metersystem comprises an ultrasonic flow meter system having first and secondultrasonic transducers.
 11. The system of claim 1, wherein the sub-searetrievable module comprises an adjustable valve disposed in the housingalong the flow path, wherein the adjustable valve is configured tocontrol the fluid flow along the flow path.
 12. The system of claim 11,wherein the sub-sea retrievable module comprises a controller configuredto adjust the adjustable valve based on a measurement by the flow metersystem.
 13. The system of claim 12, wherein the controller is configuredto adjust the adjustable valve based on the fluid pressure measured bythe pressure measurement system.
 14. The system of claim 11, wherein thesub-sea retrievable module comprises a controller configured todetermine the fluid flow of the fluid along the flow path based on themeasurement by the pressure measurement system.
 15. The system of claim14, wherein the sub-sea retrievable module comprises a valve sensorconfigured to measure a valve parameter of the adjustable valve, and thecontroller is configured to determine the fluid flow of the fluid alongthe flow path based on the measurement by the pressure measurementsystem and a measurement by the valve sensor.
 16. The system of claim15, wherein the valve sensor comprises a valve position sensor.
 17. Thesystem of claim 14, wherein the pressure measurement system comprises afirst pressure transducer disposed upstream of the adjustable valve anda second pressure transducer disposed downstream of the adjustablevalve.
 18. The system of claim 11, wherein the sub-sea retrievablemodule comprises a controller configured to adjust the adjustable valvebased on a measurement by a valve sensor associated with the adjustablevalve, an actuator sensor associated with a valve actuator coupled tothe adjustable valve, or a combination thereof.
 19. The system of claim18, wherein the valve sensor comprises a valve position sensor, theactuator sensor comprises a shaft rotation sensor, or a combinationthereof.
 20. The system of claim 11, wherein the sub-sea retrievablemodule comprises a valve actuator coupled to the adjustable valve, andthe valve actuator comprises a motor coupled to an electrical connector.21. The system of claim 1, wherein the system comprises one or moremineral extraction components coupled to the sub-sea retrievable module.22. The system of claim 1, wherein the sub-sea retrievable modulecomprises a non-return valve disposed in the housing along the flowpath.
 23. A system, comprising: a sub-sea retrievable module,comprising: a housing having a fluid inlet, a fluid outlet, and a flowpath between the fluid inlet and the fluid outlet; a non-invasive flowmeter system disposed in the housing along the flow path, wherein thenon-invasive flow meter system is configured to measure a fluid flow ofa fluid along the flow path; and a pressure measurement system disposedin the housing along the flow path, wherein the pressure measurementsystem is configured to measure a fluid pressure along the flow path,and the system is configured to determine the fluid flow of the fluidalong the flow path based on a measurement by the pressure measurementsystem.
 24. The system of claim 23, wherein the sub-sea retrievablemodule comprises an adjustable valve disposed along the flow path, andan electric actuator coupled to the adjustable valve.
 25. A system,comprising: a sub-sea retrievable module, comprising: a housing having afluid inlet, a fluid outlet, and a flow path between the fluid inlet andthe fluid outlet; an adjustable valve disposed in the housing along theflow path, wherein the adjustable valve is configured to control a fluidflow of a fluid along the flow path; a pressure measurement systemdisposed in the housing along the flow path, wherein the pressuremeasurement system is configured to measure a fluid pressure along theflow path; and a sensor disposed in the housing along the flow path,wherein the sensor is configured to measure a parameter of theadjustable valve or a valve actuator, and the system is configured todetermine the fluid flow of the fluid along the flow path based on thefluid pressure and the parameter.
 26. The system of claim 25, whereinthe sub-sea retrievable module comprises a non-invasive flow metersystem disposed in the housing along the flow path, wherein thenon-invasive flow meter system is configured to measure the fluid flowof the fluid along the flow path.
 27. The system of claim 25, whereinthe sub-sea retrievable module comprises the valve actuator coupled tothe adjustable valve, and the valve actuator comprises an electricactuator.
 28. A system, comprising: a sub-sea retrievable module,comprising: a housing having a fluid inlet, a fluid outlet, and a flowpath between the fluid inlet and the fluid outlet; and an adjustablevalve disposed in the housing along the flow path, wherein theadjustable valve is configured to control a fluid flow of a fluid alongthe flow path; an electric valve actuator disposed in the housing alongthe flow path, wherein the electric valve actuator is coupled to theadjustable valve; and a first measurement system disposed in the housingalong the flow path, wherein the first measurement system is configuredto measure a first parameter along the flow path; and a secondmeasurement system disposed in the housing along the flow path, whereinthe second measurement system is configured to measure a secondparameter along the flow path, the first and second parameters aredifferent from one another, the system is configured to calculate a flowrate of the fluid along the flow path selectively based on the firstparameter, and the system is configured to calculate the flow rate ofthe fluid along the flow path selectively based on the second parameter.29. The system of claim 28, wherein the first measurement systemcomprises a non-invasive flow meter system, and the non-invasive flowmeter system is configured to measure the fluid flow of the fluid alongthe flow path.
 30. The system of claim 28, wherein the secondmeasurement system comprises a pressure measurement system and thesecond parameter comprises a measurement by the pressure measurementsystem, the pressure measurement system is configured to measure a fluidpressure along the flow path, and the system is configured to calculatethe flow rate of the fluid along the flow path based on the measurementby the pressure measurement system.